Frac pump automatic rate adjustment and critical plunger speed indication

ABSTRACT

A method for regulating a pumping rate of an electrically powered hydraulic fracturing pump includes receiving a step rate limit for one or more pumps, the step rate limit corresponding to at least one of a minimum step rate or a maximum step rate. The method also includes determining a desired pumping rate for the one or more pumps. The method further includes determining a current rate of the one or more pumps. The method includes comparing the desired pumping rate to the current rate. The method also includes determining, based at least in part on the comparison, an adjustment to the current rate. The method further includes determining the adjustment does not exceed the step rate limit. The method includes applying the adjustment to the current rate of the one or more pumps.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims priority to and the benefit of co-pending U.S.Provisional Patent Application Ser. No. 62/821,130 filed Mar. 20, 2019titled “FRAC PUMP AUTOMATIC RATE ADJUSTMENT AND CRITICAL PLUNGER SPEEDINDICATION,” the full disclosure of which is hereby incorporated hereinby reference in its entirety for all purposes.

BACKGROUND 1. Technical Field

This disclosure relates generally to hydraulic fracturing and moreparticularly to systems and methods controlling one or more pumpoperating parameters.

2. Background

Hydraulic fracturing operations may include a number of high pressurepumps directing fluid into a common manifold or missile. Adjustments toany of the operating pumps may impact the others, and as a result, itmay be difficult to tune pumps during operations without using aniterative approach, which may be time consuming, inefficient, and coulddamage equipment. For example, pumps operating at a common flow rate orcritical plunger speed may generate impacts on the manifold or missileat the same time, which may lead to vibrational damage. Moreover,impacts at a resonance frequency may lead to damage to wellboreequipment.

SUMMARY

The present disclosure is directed to systems and methods toautomatically adjust one or more operating parameters of a pump.

In an embodiment, a method for regulating a pumping rate of anelectrically powered hydraulic fracturing pump includes receiving a steprate one or more pumps, the step rate limit corresponding to at leastone of a minimum step rate or a maximum step rate. The method alsoincludes determining a desired pumping rate for the one or more pumps.The method further includes determining a current rate of the one ormore pumps. The method includes comparing the desired pumping rate tothe current rate. The method also includes determining, based at leastin part on the comparison, an adjustment to the current rate. The methodfurther includes determining the adjustment does not exceed the steprate limit. The method includes applying the adjustment to the currentrate of the one or more pumps.

In an embodiment, a method for regulating one or more pumping rates ofan electrically powered hydraulic fracturing pump system includesreceiving a desired pumping rate for a first pump. The method alsoincludes determining a current pumping rate of an adjacent or oppositesecond pump. The method further includes determining a differencebetween the desired pumping rate and the current pumping rate is withina threshold amount. The method includes applying an adjustment to thedesired pumping rate.

In an embodiment, a hydraulic fracturing system for fracturing asubterranean formation includes a plurality of electric powered pumps,the plurality of electric powered pumps coupled to a well associatedwith the subterranean formation and powered by at least one electricmotor, the plurality of electric powered pumps configured to pump fluidinto a wellbore associated with the well at a high pressure so that thefluid passes from the wellbore into the subterranean formation andfractures the subterranean formation. The system also includes one ormore sensors receiving operating information from the plurality ofelectric powered pumps. The system further includes a control systemreceiving the operating information and controlling at least oneoperating parameter of the plurality of electric powered pumps, whereinthe control system is configured to apply respective step rates toadjust respective pumping rates for the plurality of electric poweredpumps.

In an embodiment, adjustable minimum and maximum step changes in speedadjustment for frac pumps are incorporated into a pumping controlsystem.

In an embodiment, automatic adjustments of frac pump flow rates areincorporated into a pumping control system. The adjustments may be tooptimized speeds to avoid synchronization of plunger strokes with otherpumps that are pumping into the same discharge manifold while holdingthe overall flow rate of the collective group of frac pumps constant.

In an embodiment, critical plunger speed indicators are incorporatedinto a pumping control system. The indicators may alert the frac pumpoperator when any manual adjustments may lead to increased individualpump rates that may result in the critical plunger speed being reachedor warned that the critical speed is being approached.

BRIEF DESCRIPTION OF DRAWINGS

Some of the features and benefits of the present disclosure having beenstated, others will become apparent as the description proceeds whentaken in conjunction with the accompanying drawings, in which:

FIG. 1 is a schematic plan view of an embodiment of a fracturingoperation, in accordance with embodiments of the present disclosure;

FIG. 2 is a block diagram of an embodiment of a fracturing pump, inaccordance with embodiments of the present disclosure;

FIG. 3 is a block diagram of an embodiment of a control system utilizingwith a pumping system, in accordance with embodiments of the presentdisclosure;

FIG. 4 is a flow chart of an embodiment of a method for adjusting a pumprate, in accordance with embodiments of the present disclosure;

FIG. 5 is a flow chart of an embodiment of a method for adjusting a pumprate, in accordance with embodiments of the present disclosure;

FIG. 6 is a flow chart of an embodiment of a method for adjusting a pumprate, in accordance with embodiments of the present disclosure; and

FIG. 7 is a flow chart of an embodiment of a method for adjusting a pumprate, in accordance with embodiments of the present disclosure.

While the disclosure will be described in connection with the preferredembodiments, it will be understood that it is not intended to limit thedisclosure to that embodiment. On the contrary, it is intended to coverall alternatives, modifications, and equivalents, as may be includedwithin the spirit and scope of the disclosure as defined by the appendedclaims.

DETAILED DESCRIPTION

The method and system of the present disclosure will now be describedmore fully hereinafter with reference to the accompanying drawings inwhich embodiments are shown. The method and system of the presentdisclosure may be in many different forms and should not be construed aslimited to the illustrated embodiments set forth herein; rather, theseembodiments are provided so that this disclosure will be thorough andcomplete, and will fully convey its scope to those skilled in the art.Like numbers refer to like elements throughout. In an embodiment, usageof the term “about” includes +/−5% of the cited magnitude. In anembodiment, usage of the term “substantially” includes +/−5% of thecited magnitude.

It is to be further understood that the scope of the present disclosureis not limited to the exact details of construction, operation, exactmaterials, or embodiments shown and described, as modifications andequivalents will be apparent to one skilled in the art. In the drawingsand specification, there have been disclosed illustrative embodimentsand, although specific terms are employed, they are used in a genericand descriptive sense only and not for the purpose of

When introducing elements of various embodiments of the presentdisclosure, the articles “a”, “an”, “the”, and “said” are intended tomean that there are one or more of the elements. The terms “comprising”,“including”, and “having” are intended to be inclusive and mean thatthere may be additional elements other than the listed elements. Anyexamples of operating parameters and/or environmental conditions are notexclusive of other parameters/conditions of the disclosed embodiments.Additionally, it should be understood that references to “oneembodiment”, “an embodiment”, “certain embodiments”, or “otherembodiments” of the present disclosure are not intended to beinterpreted as excluding the existence of additional embodiments thatalso incorporate the recited features. Furthermore, reference to termssuch as “above”, “below”, “upper”, “lower”, “side”, “front”, “back”, orother terms regarding orientation or direction are made with referenceto the illustrated embodiments and are not intended to be limiting orexclude other orientations or directions. Additionally, recitations ofsteps of a method should be understood as being capable of beingperformed in any order unless specifically stated otherwise.Furthermore, the steps may be performed in series or in parallel unlessspecifically stated otherwise.

Various control systems may be utilized to adjust minimum and maximumstep changes for hydraulic fracturing pumps. For example, the pumps maybe controlled via software that sends a signal to adjust one or morecomponents of the hydraulic fracturing pumps, such as adjusting a speedof a corresponding motor. However, systems may be limited to banks ofpumps (e.g., pump groups) that are utilized during a fracturing process.As a result, an adjustment to one pump may be propagated to the entirebank of pumps, which may be undesirable. Embodiments of the presentdisclosure enables software to determine and manage individual minimumand maximum step changes for each pump, independent of other pumps ofthe group or at the well site. As a result, particularized adjustmentsmay be made, which may improve the pumping operation. Moreover, the stepvalues may be stored and reported in common units that are easy for anoperator to understand, such as barrels per min, gals, or the like. Thisimproves traditional reporting systems that relay information in termsof motor rpm (e.g., electric motor rpm for electric frac pumps orengine, transmission, or pump rpm for diesel frac pumps). As a result,the operator may have a better understanding of how adjustments willimpact pumping operations, as it may be easier to visualize a volumetricmeasurement of flow rather than a rotating speed of a component of thepump.

Embodiments of the present disclosure provide automated adjustments tofrac pump flow rates to avoid or reduce the likelihood ofsynchronization of plunger strokes between pumps pumping into a commonside of a discharge manifold. Moreover, embodiments of the presentdisclosure further adjust frac pump flow rates to maintain an overallflow rate of the collective group of pumps. Such an automated processprovides an improvement over current, manual, iterative processes. Thatis, operators may adjust flow rate of one pump, evaluate pumpingconditions, adjust a different pump, and so forth until a desiredoperating condition is achieved. This process is inefficient and couldlead to damage to pumping components.

In various embodiments, data obtained from previous pumping operationsmay be utilized to predict or otherwise anticipate frac pump criticalplunger speeds for a variety of pumping operations. That is,relationships may be developed, through data analysis, to correlatecertain operating conditions to one or more desirable or undesirablestates of operation. In other words, data may be utilized to determineor estimate a frac pump critical plunger speed, which may be referred tothe plunger speed at which conditions for pump cavitation to occur areimpending, based on the speed of the pump plungers and the accelerationhead of the fluid moving into the plunger bores.

FIG. 1 is a plan schematic vie of an embodiment of a hydraulicfracturing system 10 positioned at a well site 12. In the illustratedembodiment, pumps 14 (which may be arranged one or more trailers, skids,or the like), making up a pumping system 16, are used to pressurize aslurry solution for injection into a wellhead 18. An optional hydrationunit 20 receives fluid from a fluid source 22 via a line, such as atubular, and also receives additives from an additive source 24. In anembodiment, the fluid is water and the additives are mixed together andtransferred to a blender unit 26 where proppant from a proppant source28 may be added to form the slurry solution (e.g., fracturing slurry)which is transferred to the pumping system 16. The pumps 14 may receivethe slurry solution at a first pressure (e.g., 80 psi to 160 psi) andboost the pressure to around 15,000 psi for injection into the wellhead18. In certain embodiments, the pumps 14 are powered by electric motors.

After being discharged from the pump system 16, a distribution system30, such as a missile, receives the slurry solution for injection intothe wellhead 18. The distribution system 30 consolidates the slurrysolution from each of the pumps 14 and includes discharge piping 32coupled to the wellhead 18. In this manner, pressurized solution forhydraulic fracturing may be injected into the wellhead 18.

In the illustrated embodiment, one or more sensors 34, 36 are arrangedthroughout the hydraulic fracturing system 10 to measure variousproperties related to fluid flow, vibration, and the like.

It should be appreciated that while various embodiments of the presentdisclosure may describe electric motors powering the pumps 14, inembodiments, electrical generation can be supplied by various differentoptions, as well as hybrid options. Hybrid options may include two ormore of the following electric generation options: Gas turbinegenerators with fuel supplied by field gas, CNG, and/or LNG, dieselturbine generators, diesel engine generators, natural gas enginegenerators, batteries, electrical grids, and the like. Moreover, theseelectric sources may include a single source type unit or multipleunits. For example, there may be one gas turbine generator, two gasturbines generators, two gas turbine generators coupled with one dieselengine generator, and various other configurations.

In various embodiments, equipment at the well site may utilize 3 phase,60 Hz, 690V electrical power. However, it should be appreciated that inother embodiments different power specifications may be utilized, suchas 4160V or at different frequencies, such as 50 Hz. Accordingly,discussions herein with a particular type of power specification shouldnot be interpreted as limited only the particularly discussedspecification unless otherwise explicitly stated. Furthermore, systemsdescribed herein are designed for use in outdoor, oilfield conditionswith fluctuations in temperature and weather, such as intense sunlight,wind, rain, snow, dust, and the like. In embodiments, the components aredesigned in accordance with various industry standards, such as NEMA,ANSI, and NFPA.

FIG. 2 is a schematic diagram of an embodiment of a fracturing pump 200that includes a reciprocating plunger 202. It should be appreciated thatthe embodiment illustrated in FIG. 2 is simplified and has removedseveral components for clarity with the discussion herein. A fluid inlet204 draws low pressure fluid into a pump body 206 and movement of theplunger 202 increases the pressure as the fluid exits the outlet 208. Itshould be appreciated that the illustrated embodiment is forillustrative purposes only and that other types of pumps may be used,such as centrifugal pumps and the like. As described above in variousembodiments, the speed of the plunger 202 may be indicative ofcavitation within the pump 200. As would be known, cavitation refers tothe formation of vacuum bubbles in a liquid in which the liquid's vaporpressure has been reached. It is the implosion of these vacuum bubblescaused by movement of the plunger which may generate shock waves. Thismay lead to pitting in components of the pump 200 or undesirablevibrations, both of which can decrease the life of the pump 200.

FIG. 3 illustrates an example pumping configuration 300 including aplurality of pumps (P) 200 coupled to a manifold 302. It should beappreciated that the six pumps 200 shown in FIG. 3 are for illustrativepurposes only and that other embodiments may include more or fewerpumps. Furthermore, the illustrated embodiments include a commonmanifold 302, but there may be other piping configurations used invarious embodiments.

The pumps 200 are also communicatively coupled to a control system 304that includes a controller 306, a memory 308, and a processor 310. Inthe illustrated embodiment, the control system 304 is coupled to eachpump 200 of the plurality of pumps 200 and may be configured toindividually control one or more aspects of operation of the pump 200,such as modifying conditions of the pump itself or associatedcomponents, such as upstream valves or a motor (e.g., an electric motor,a diesel powered motor) coupled to the pump (not pictured).

Embodiments of the present disclosure are directed to systems andmethods for monitoring and/or adjusting operation of one or more pumps200 within a group during a fracturing operation in order to reduce thelikelihood of cavitation, among other effects, without impacting anoverall group flow rate.

For example, the pump 200 may be communicatively coupled to a controller306 that adjusts a minimum and maximum step change for the pump 200during speed adjustments. As would be appreciated, the step changerefers to a rate of change between two different operating points, suchas speed. In various embodiments, the control system 304 may includeexecutable programming code, for example stored on the memory device308, that enables the pump operator to enter the minimum and maximumstep rates that can be selected while increasing or decreasing pumprates as required in hydraulic fracturing. The step rates can be chosensuch that no adjacent or opposite pumps connected to either the missiletrailer or the suction and discharge ground manifold will have the samestep changes while increasing or decreasing pump rates. As a result,operating using the control system 304 minimizes the chances of pumpsrunning at synchronized plunger speeds that could introduce a harmonicvibration into the connected equipment system.

In the example described above, step changes between the pumps may beprogrammed as maximum and minimum values in order to reduce upsets inoperation. Furthermore, changes between associated pumps (e.g., a groupof pumps on one side of the manifold, opposite facing pumps across themanifold, etc.) may be adjusted in response to adjustments to one ormore associated pumps. For example, in the embodiment of FIG. 3, thepumps 200 may be labeled with letters, such as pumps 200A-200F. Eachpump may have a different step change or pump rate. Embodiments of thepresent disclosure may be directed toward eliminating situations wherepump rates of adjacent or opposite facing pumps are the same or within athreshold amount. By way of example only, a pump rate associated withthe pump 200A would be different from the pump rates for 200B and 200D.Similarly, a pump rate for 200B would be different from pump rates for200A, 200C, and 200E.

Additional embodiments may provide automatic pump rate adjustment. Forexample, a pump operator can choose any or all of the frac pump that areconnected for hydraulic fracturing operations to be active and thenenter the desired total downhole pump rate for that collection of pumpsinto a human-machine interface (HMI) screen for pump control. The pumpoperator an then manually increase or decrease pump rates utilizing thefeature above (e.g., adjustable minimum and maximum step rate changes)for all of the selected active frac pumps. As a result, the desired flowrate may be changed in stages or gradually to reduce the likelihood ofequipment upsets.

Furthermore, when the pump operator gets fairly close (e.g., within athreshold) to the overall desired flow rate of the collective pumps, thecontrol system 304 may be utilized to automatically fine tune the rateson each pump 200 such that no adjacent or oppositely positioned pumpsare within 5% (adjustable) of the same crankshaft rpm (or motor rpm ifan electric motor is turning the pump), while maintaining the desiredconstant total flow rate. Information regarding flow rates, motor rpm,crankshaft rpm, and the like may be provided to the control system viaone or more sensors 312 that may be arranged around and/or on the pump,such as the sensors 34, 36 shown in FIG. 1.

In various embodiments, a damage accumulation calculation factor mayalso be incorporated into the control system 304 to adjust operation ofone or more pumps 200. The damage accumulation calculation factorprovides information associated with a likelihood of damage exhibited bya pump. As a result, the control system may utilize a damage thresholdto control operation and/or adjustments to the pump. For example, basedat least in part the damage accumulation calculation factor, the controlsystem could intelligently not speed up a pump exhibiting a high damageaccumulation factor, and likewise apply speed increase to only thosepumps with lower damage accumulation factors. The speed differentialsshould eliminate “superposition” of vibration (also termed as “beatingphenomenon”) within the piping system due to adjacent pumps withsynchronized plunger flow ripple patterns. This process could then berepeated for any more pumps that the operator would like to bring online.

In various embodiments, the pump operator could use the processdescribed above, but eliminate the task of initially increasing ordecreasing pump rates manually to the desired overall flow rate of theselected active frac pumps by simply activating the control system toautomatically adjust individual pump rates and fine tune as above.

Furthermore, embodiments of the present disclosure may include acritical plunger speed indicator. As described above, this indicatorcould be utilized as a form of software stored as executableinstructions on the memory 308. In various embodiments, the indicatorwould enable an alert to a hydraulic fracturing pump operator as to whenthe critical plunger speed has been reached. In certain embodiments, thecritical plunger speed may be determined based on past operatingconditions of a variety of pumps in a variety of circumstances.Accordingly, one or more ore measureable factors at the site may beutilized to predict and/or determine the plunger speed and analyzewhether the plunger speed is within a threshold amount of a calculatedand/or predetermined critical plunger speed. For example, criticalplunger speed may be directly proportional to pump crankshaft rpm, atwhich conditions above this critical speed are favorable for pumpcavitation to exist. When this pump speed is reached, the pump operatorcould receive a notification (e.g., a notation with text, colored lightsbeginning with yellow and changing to orange and red as the pump speedis increased more, auditory alarms, or the like).

Embodiments of the present disclosure may provide a variety ofadvantages of existing methods. For example, adjustable minimum andmaximum step changes for frac pump speed adjustment may minimize thelikelihood of pumps running at synchronized plunger speeds that couldintroduce a harmonic vibration into the connected equipment system.Furthermore, the above-described automatic pump rate adjustment mayeliminate or reduce the likelihood of “superposition” of vibration (alsotermed as “beating phenomenon”) within the piping system due to adjacentand oppositely positioned pumps with synchronized plunger flow ripplepatterns. Moreover, the critical plunger speed indicator may provide analert prior to an operating condition that could lead to pumpcavitation, thereby reducing the likelihood of equipment damage.

It should be appreciated that a variety of adjustments may be presentedto the embodiments described herein. By way of example only, rather thanincluding a large or small step between speed changes, the pump ratecould simply be entered for the desired new rate. The system could thendetermine the proper adjustment to reach the desired new rate. Moreover,various embodiments may include a dial, physical or digital, that allowsthe pump operator to turn up the rate. Furthermore, there could be allthree, a desired rate entry, large and small steps, and a dial. Then thepump operator can enter in speeds as is most convenient to the pumpoperator.

It should be appreciated that embodiments herein may utilize one or morevalues that may be experimentally determined or correlated to certainperformance characteristics based on operating conditions under similaror different conditions. For example, information may be collected fromhydraulic fracturing pumps operating in a variety of conditions and atdifferent operating points (e.g., different flow rates, differentpressures, different stages of maintenance cycles, etc.). Thereafter,measurements may be analyzed in view of triggering events, such ascavitation, high vibration, pump failures, or the like. Over time,information may be identified as being indicative or related to one ormore triggering events. Such information may be normalized or otherwiseadjusted based on other factors, such as operating conditions, toestablish threshold values to utilize as indications in the embodimentsdescribed herein. For example, rather than a specific number (e.g., Xrpm) the threshold may be a percentage of a measurement components(e.g., within X % of redline rpm). In various embodiments, redline rpmmay refer to a maximum engine speed at which a motor is designed tooperate. However, it should be appreciated that a redline may be definedas a desired maximum operating speed and may not necessarily be themaximum engine speed.

FIG. 4 is a flow chart of a method 400 for adjusting a pump step rate.It should be appreciated that for this method, and all methods describedherein, that the steps may be performed in a different order, or inparallel, and there may be more or fewer steps unless otherwisespecifically stated. In this example, a minimum and/or maxim step rateis received for one or more pumps 402. For example, an operator may loaddesirable minimum and/or maximum step rates and/or a database mayprovide information including the information. A desired pumping ratemay be determined 404. This desired pumping rate may be associated withthe set of pumps as a whole, with one individual pumps, with a subset ofpumps, or the like. The desired rate may be determined by an operatorand/or by a database or other information available to the controller. Acurrent pumping rate is determined and evaluated as being different fromthe desired rate 406. For example, the current pumping rate may behigher or lower. As a result, an adjustment is determined 408 in orderto bring the pump to the desired rate. The adjustment is comparedagainst the previously received limits 410. If the adjustment exceedsthe limits, then a new adjustment is computed. If the adjustment iswithin the limits, the adjustment is applied 412. In this manner,automatic tuning is enabled that may be constrained within predeterminedranges.

FIG. 5 is a flow chart for an embodiment of a method 500 for adjusting astep rate based on adjacent or opposite pumping configurations. In thisexample, a desired pumping rate for a pump is determined 502. As notedabove, it may be undesirable for adjacent or opposite pumps to havesimilar pumping rates, therefore, embodiments also determine a currentpumping rate of at least an adjacent or opposite pump 504. The desiredpumping rate is then compared to the current pumping rate or theadjacent or opposite pump 506. The difference is evaluated against athreshold 508, and if the rates are within the threshold, at least oneof the desired rate or the current rate is modified 510 before themodification is applied to the pump 512. If the rates are not within athreshold, the modification is applied to the pump to change the pumpingrate to the desired pumping rate.

FIG. 6 is a flow chart of an embodiment of a method 600 for adjustingpumping rates for a group of pumps. In this example, a desired overallpumping rate for a group of pumps is determined 602. A respectivepumping rate for each pump of the groups of pumps may be determined 604,where each pump may have a different rate. Current respective pumpingrates for each pump are also determined 606. Thereafter, an adjustmentrate for each pump is determine for bringing the respective pumps to thedesired overall rate 608. The adjustment rates are evaluated against athreshold 610. If the rate exceeds the threshold, new adjustment ratesare determined. If the rate does not exceed the threshold, theadjustment is applied 612. In this manner, individual adjustments may bemade to pumps to achieve a desired overall rate.

FIG. 7 is a flow chart of an embodiment of a method 700 for determininga desired pumping rate, which may be based at least n part on speed,based at least in part on a calculated damage accumulation factor. Thisexample begins with receiving a desired pumping rate and/or speed for apump 702. For example, an operator or database may provide informationto a controller that automatically adjusts pumping rates, A damageaccumulation rate may be calculated for the pump 704. As noted above,the damage accumulation rate may be indicative of pump health and/orsuitability for operation. A high damage accumulation rate may berelated to a pump that preferably is not operated at high speeds, forexample. The damage accumulation is evaluated against a threshold 706,such as a value or percentage. If the damage accumulate exceeds thethreshold, a warning may be provided 708. If not, then a step rate maybe determined to adjust the pump 710. This step rate may also beevaluated against a threshold 712. If the step rate does not exceed thethreshold, then the rate is applied 714. If it does exceed thethreshold, then a new step rate may be determined. Accordingly, changesin pump operation may be made, at least in part, based on a damageaccumulation rate.

The present disclosure described herein, therefore, is well adapted tocarry out the objects and attain the ends and advantages mentioned, aswell as others inherent therein. While a presently preferred embodimentof the disclosure has been given for purposes of disclosure, numerouschanges exist in the details of procedures for accomplishing the desiredresults. These and other similar modifications will readily suggestthemselves to those skilled in the art, and are intended to beencompassed within the spirit of the present disclosure disclosed hereinand the scope of the appended claims.

1. A method for regulating a pumping rate of an electrically poweredhydraulic fracturing pump, comprising: receiving a step rate limit forone or more pumps, the step rate limit corresponding to at least one ofa minimum step rate or a maximum step rate; determining a desiredpumping rate for the one or more pumps; determining a current rate ofthe one or more pumps; comparing the desired pumping rate to the currentrate; determining, based at least in part on the comparison, anadjustment to the current rate; determining the adjustment does notexceed the step rate limit; and applying the adjustment to the currentrate of the one or more pumps.
 2. The method of claim 1, furthercomprising: determining a damage accumulation rate for the one or morepumps; and determining the damage accumulation rate is below athreshold.
 3. The method of claim 1, further comprising: determining adamage accumulation rate for the one or more pumps; determining thedamage accumulation rate exceeds a threshold; and transmitting awarning.
 4. The method of claim 1, wherein the desired pumping ratecorresponds to at least a fraction of a desired overall pumping rate fora group of pumps.
 5. The method of claim 4, wherein at least two pumpsof the group of pumps operates at a different pumping rate.
 6. Themethod of claim 4, wherein at least two pumps of the group of pumps havedifferent adjustments.
 7. The method of claim 1, wherein information istransmitted from the one or more pumps from respective sensors.
 8. Amethod for regulating one or more pumping rates of an electricallypowered hydraulic fracturing pump system, comprising: receiving adesired pumping rate for a first pump; determining a current pumpingrate of an adjacent or opposite second pump; determining a differencebetween the desired pumping rate and the current pumping rate is withina threshold amount; applying an adjustment to the desired pumping rate.9. The method of claim 8, further comprising: determining the differencebetween the desired pumping rate and the current pumping rate exceeds athreshold amount; and modifying at least one of the current pumping rateor the desired pumping rate.
 10. The method of claim 8, furthercomprising: determining a step rate for the first pump.
 11. The methodof claim 8, wherein the step rate is based, at least in part, on a pumpspeed, crankshaft rpm, or critical plunger speed.
 12. The method ofclaim 8, wherein the desired pumping rate corresponds to at least afraction of a desired overall pumping rate for a group of pumps.
 13. Themethod of claim 8, wherein information is transmitted from the one ormore pumps from respective sensors.
 14. The method of claim 8, whereinthe desired pumping rate is transmitted from at least one of an operatorat a well site or a database communicatively coupled to a controllerassociated with the first pump.
 15. The method of claim 8, furthercomprising: determining a damage accumulation rate for the first pump;and determining the damage accumulation rate is below a damagethreshold.
 16. The method of claim 8, further comprising: determining adamage accumulation rate for the first pump; determining the damageaccumulation rate exceeds a damage threshold; transmitting a warning.17. The method of claim 16, further comprising: receiving confirmation,from an operator, to apply the adjustment.
 18. A hydraulic fracturingsystem for fracturing a subterranean formation, comprising: a pluralityof electric powered pumps, the plurality of electric powered pumpscoupled to a well associated with the subterranean formation and poweredby at least one electric motor, the plurality of electric powered pumpsconfigured to pump fluid into a wellbore associated with the well at ahigh pressure so that the fluid passes from the wellbore into thesubterranean formation and fractures the subterranean formation; one ormore sensors receiving operating information from the plurality ofelectric powered pumps; and a control system receiving the operatinginformation and controlling at least one operating parameter of theplurality of electric powered pumps, wherein the control system isconfigured to apply respective step rates to adjust respective pumpingrates for the plurality of electric powered pumps.
 19. The system ofclaim 18, wherein a first pump of the plurality of electric poweredpumps is at least one of adjacent to or opposite a second pump of theplurality of electric powered pumps, and the first pump and the secondpump operate at different pumping rates.
 20. The system of claim 18,wherein a total pumping rate for the plurality of electric powered pumpsis controlled by the control system, the control system configured toindividually adjust pumps of the plurality of electric powered pumps.